Schlumberger

Technical Paper: Real Time Integration of Reservoir Modeling and Formation Testing

Society: SPE
Paper Number: 121275
Presentation Date: 2009
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Abstract

The increasing complexities of newly discovered reservoirs coupled with the increasing cost structure of field development mandate significantly improved and timely work flows for reservoir evaluation. Traditional modeling workflows are typically time consuming and require well organized cross disciplinary integration between geoscientists. Such models and processes are not well suited to be used and updated during formation evaluation acquisition phases of field development. In this paper a more accessible approach is proposed and demonstrated. The existing fluids model is combined with the current geologic model to construct an accurate representation of key features of the reservoir. This model is then used to predict data for a wireline formation sampling and testing tool (WFT), with emphasis on downhole fluid analysis (DFA). In this process, current reservoir understanding is tested by direct measurement in real time. If differences are uncovered between predicted and measured log data, the WFT tool is in the well, and measurements can be made to uncover the source of the error.

In this paper a workflow is demonstrated where WFT DFA and PVT lab reports were used to build a fluid model after the first exploration well data was acquired. This model was then used to predict fluid properties and WFT DFA logs for a subsequent well intersecting nominally the same compartment. These DFA predictions presumed fluid equilibrium and flow connectivity. Real-time comparisons were made of predicted and measured pressures, fluid gradients, contacts and DFA data obtained from the WFT logging run. Agreement of predicted and measured log data indicates that fluid properties and reservoir connectivities used for the modeling are correct. If predictions disagree with measurements the acquisition program can be altered in real time to ensure sufficient data is acquired to understand the reservoir model inaccuracies.

During the WFT logging job, this predictive model enabled validation of critical WFT data. This process also allowed testing of the reservoir connectivity. It was discovered that either compartmentalization or lateral disequilibrium of the fluids in the reservoir exists. Interpretation of the DFA data suggested that a subtle lateral disequilibrium exists and the assumption of reservoir connectivity is supported.

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